Brazil's GNA II halts power generation indefinitely

Market: Electricity, Natural gas
20/08/26

Brazilian power firm GNA halted power generation from the GNA II natural gas-fired power plant after a technical failure damaged the plant's operation on 10 August, it said on 19 August.

The 1.7GW GNA II plant is located in Acu port in southeastern Rio de Janeiro state, and is fired by LNG. It is Brazil's largest operating thermoelectric plant.

GNA is assessing the cause of the failure and has no timeframe for operations to return, it said. The company also notified national grid operator ONS about the issue and it has been taken into consideration in ONS' latest operational schedule.

The LNG terminal, the regasification terminal and the GNA I plant close to GNA II were unharmed by the failure and are operating normally. There were no victims nor environmental damage, GNA said.

By Maria Frazatto

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20/08/26

US high-balling Hormuz energy flows

New York, 20 August (Argus) — US officials continue to claim a high number of tankers are exiting the strait of Hormuz through US-assisted transits, despite vessel tracking and satellite information pointing to much lower traffic through the strait. "Right now, the strait is open. A lot of boats are coming through. We are getting a lot of oil out," US President Trump said on 19 August at the White House. But vessel information firm TankerTrackers.com said on 20 August that only 5mn b/d is departing the US Navy blockade line regardless of where the loading or transfer of crude is taking place, in response to claims by US officials that 10mn b/d are traveling through the strait of Hormuz. The US-imposed blockade on Iranian ports is being enforced from outside the strait of Hormuz between the Gulf of Oman and the Arabian Sea, so the TankerTrackers.com figure likely includes loadings at the UAE and Oman's eastern ports within the Gulf of Oman, beyond the confines of the strait itself. US Energy Secretary Chris Wright claimed last week that an average of 9mn b/d exited the strait of Hormuz, a figure much higher than available information. "We do have control of the strait, you would have seen media reports that large amounts of energy are getting out, and you know I think that we can continue doing that in the southern lane," US Treasury Secretary Scott Bessent in an interview with CNBC on 20 August. Available vessel tracking and satellite data does not corroborate the assertions made by US officials that many tankers are going through the strait of Hormuz on the US' southern transit lane. Some tanker traffic is occurring through the strait, undetected by conventional vessel tracking systems since vessels are transiting with their automatic identification systems off. But these transits are visible through satellite imagery, on both the US-supported southern lane and the northern Iranian-controlled lane, data from maritime security firm Windward shows. These observable flows are at a fraction of pre-war levels, while many vessels transiting through the southern lane have been subject to attacks by Iranian forces. Tanker flows through the strait of Hormuz itself are projected by vessel tracking firm Vortexa to stand at around 941,400 b/d for the period of 14-21 August, comprised mostly of Iraqi and Saudi shipments. Most of the energy that is leaving the Mideast Gulf following the outbreak of the US-Iran war is doing so through the UAE and Oman's eastern ports. Estimates from Vortexa place exports via Fujairah port in the week between 14-21 August around 2.06mn b/d while exports via Sohar and Muscat, Oman, totaled around 1.15mn b/d in the same period. Vessel tracking data shows around 4mn b/d total departing from around the Mideast Gulf, including flows through Hormuz, in the last week. The White House did not respond to a request for comment from Argus to provide additional details on the US' efforts to support tanker transits through the strait of Hormuz. Hormuz tanker traffic on Iranian lanes up Vessel traffic through the strait of Hormuz over the last 24 hours totaled 16 vessels, mostly transiting through the northern, Iranian-controlled transit lane, split between 10 inbound transits and six outbound transits, data from maritime security firm Windward shows. Tanker traffic totaled 12 vessels, split between seven inbound and five outbound transits, most of which took place on the northern lane, Windward data shows. The Liberia-flagged Sweden Prosperity and the Hong Kong-flagged Hestia transited the strait inbound through the southern corridor, Windward data shows. However, the Hestia has turned back following its successful inbound transit and is currently idling off the eastern coast of the UAE, data from vessel tracking service Vortexa shows. The Hestia is one of at least two China-affiliated very large crude carriers to abandon its transits through the strait of Hormuz over the last few days. The remaining five inbound transits took place on the northern, Iranian controlled lane, according to Windward. For outbound transits, a single transit took place on the US-supported southern lane, Windward tracked the Ashley which transited dark. The Ashley is laden with 469,000 bl of fuel oil it loaded at Dubai lightering area on 16 August and is currently idling off Fujirah, according to Kpler data. By Charlotte Bawol Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.

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Indonesia solar groups seek better land, permit rules

20/08/26

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20/08/26

Indonesia solar groups seek better land, permit rules

Singapore, 20 August (Argus) — Indonesia's solar power developers are hoping for improved land acquisition and permitting rules to help boost project development as the country seeks to scale up photovoltaic generation in the coming years, delegates heard at the Indonesia Sustainable Energy Week conference on 19 August. Developers currently face different land approval processes across Indonesia, which is a significant issue since solar projects often require large land areas, said Mada Habsari, chairperson of the Indonesian Solar Energy Association (AESI). Land acquisition has been in the spotlight since Indonesian president Prabowo Subianto firmed up a 100GW national solar target last year, up from under 2GW currently. Vacant mining land in regions such as East Kalimantan and South Sumatra, could be used for solar facilities — on top of the more frequently discussed ground-mounted or reservoir floating models, said vice-president at state utility PLN, Ricky Faizal. The government has identified about 9,000 hectares of land to help advance an initial 30GW tranche of the national 100GW solar target, said deputy minister for energy and mineral resources Yuliot Tanjung on the sidelines of the conference. AESI believes PLN's process for selecting private developers for new solar projects could be further improved. There have been projects that have been awarded for construction based on lowest tariff bid, but subsequently fell through because land could not be acquired, said Refi Kunaefi, AESI's lead for the independent power producers taskforce. An alternative approach where PLN requests initial plans from developers first, and then provides up to a year to secure land tenure before negotiating the final tariff rates, could be more feasible, Refi said. Any changes to how state agencies engage private developers for renewable energy could be significant — the country's 10-year power development plan envisions the private sector to undertake over 70pc of new clean energy buildouts up to 2034. Rooftop backlog Demand for industrial and rooftop solar systems has grown quickly in the past two years, because of sustainability requirements multinational companies operating in Indonesia abide by, and more recently as a response to diesel shortages, said Emmanuel Jefferson Kuesar, chief executive of developer Sun Energy. But the company has had to delay clients because Indonesia's rooftop solar quarter has been fully subscribed, he said. Indonesia allocated about 485MW for grid-connected rooftop installations at the start of the year — 304MW of which were for projects already previously on waitlist. More broadly the latest 10-year power development plan envisions over 3GW of rooftop solar additions between 2025-2034, split into yearly quotas. Rooftop solar development for now will be guided by quotas, which are updated every six months to a year, said Ricky. The utility is seeking to improve power system flexibility, and modernise distribution networks, to support a greater input of renewable power, he said. Indonesia currently has over 120 solar facilities of under 1MW — the typical size of commercial rooftop installations — registered to issue I-RECs. Current-year Indonesian solar I-RECs were recently offered at under $3/MWh. Financing headwinds Project financing remains yet another roadblock, developers said, citing both institutional rules and recent headwinds. Indonesian officials have often discussed the 100GW solar goal as spurring rural electrification and reducing dependency on diesel generators. But distributed rural projects are harder to finance because of their smaller scale, Mada said. The AESI is working on aggregating rural projects to improve their financing prospects, and seeking blended financing opportunities, she said. Some renewables projects that were previously bankable have been negatively affected by Indonesia's weakening currency and rising lending rates in the past months. Some institutional investors also have blanket bans on sectors such as mining, which becomes a roadblock to building solar projects for mining firms, Kuesar said. But there are still opportunities with investors such as pension funds seeking long-term stable returns, since solar projects can sign power supply agreements of 20-25 years, he said. By Liang Lei Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.

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Asia power grid delay may incur billions in cost: Ember

20/08/26

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20/08/26

Asia power grid delay may incur billions in cost: Ember

Singapore, 20 August (Argus) — Delays in the development of the Asean Power Grid (APG) could result in billions of dollars in economic losses for the region and alter energy transition pathways, according to a report by think-tank Ember. Members of the Association of Southeast Asian Nations (Asean) have announced their target to establish the Asean power grid by 2045 . Under an assumed completion date of 2035, each year that the project is delayed beyond this will add $2.6bn in economic losses, according to the report released today by Ember. A five-year delay for the APG would cost the region almost $14bn, as well as 55bn m³ of additional gas, and over 71mn t of CO2 emissions. Ember uses 2035 as the baseline year, based on Singapore's plan to import 6GW of power via interconnections by then, as well as regional ambitions such as a 2,000MW Malaysia-Singapore interconnection targeted to begin operating in 2030. Asean's power demand is set to continue rising because of industrial growth, data centres, electrification, and cooling demand. Electricity demand in southeast Asia is set to almost double to 2,000 TWh/yr in 2050 from 1,300 TWh/yr today, according to energy watchdog the International Energy Agency (IEA). Coal and gas generated over 73pc of the region's electricity demand in 2025, compared with 5pc from solar and wind, according to Ember. Asean's vulnerability because of its reliance on fossil fuel imports has become apparent especially because of the US-Iran war. Southeast Asia gets about a third of its oil and refined products from the Middle East, and the conflict has raised regional gas prices by as much as 60pc compared with pre-war levels, the report said. Some countries offer subsidies to help absorb some of these price shocks, but "for economies that depend on affordable power to support industry and attract investment, this exposure is a major risk to economic competitiveness," the report said. The region's energy import bill is projected to reach a record $160bn this year, and is set to increase further in the decades ahead, potentially rising to $400bn, or 5pc of its economy, by 2050 based on current policy settings, according to the IEA. A five-year delay in the establishment of the APG would also mean 7.2GW of solar power would not be developed in Asean in 2035. Singapore would have to install an additional 300MW of gas-fired capacity to meet demand in 2035 locking in fossil fuel infrastructure with economic lifetimes that can span 25 years, as well as take-or-pay contracts, and this could extend fuel imports. Countries with abundant renewables such as Indonesia, Laos, Cambodia and Myanmar could collectively lose $1.1bn in revenue for each year the APG is delayed because they would be unable to monetise renewable resources through power exports, according to the report. Recommendations The APG would link national power systems to enable the sharing of reserve capacity to offset local shortages, and enhance system security, reliability and market efficiency, including through reducing the need for conventional plants or battery storage, the report said. It would also enable renewable energy to be developed where resources are most cost-effective. For the APG to materialise, political discourse needs to shift away from just discussions to commitment that extends beyond electoral cycles, and this has to be supported by working-level co-ordination, the report said. The Lao PDR–Thailand–Malaysia–Singapore Power Integration Project (LTMS-PIP) demonstrates that such co-operation is possible. Secondly, cross-border projects need to be made bankable through harmonised and transparent tariff frameworks and regionally co-ordinated wheeling charges. Cost sharing should also be done fairly, whereby costs are allocated according to each party's perceived benefits. Regional financing mechanisms such as the Asean Power Grid Financing Initiative are also important in mobilising capital. Lastly, while bilateral projects are more pragmatic in the near term because they require less harmonisation of regulatory frameworks and implementation timelines, their governance and institutional frameworks from the outset should be built with a view to expand easily into multilateral power trade, Ember said. By Prethika Nair Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.

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Australia’s APA completes Sturt plateau gas pipeline

20/08/26

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20/08/26

Australia’s APA completes Sturt plateau gas pipeline

Sydney, 20 August (Argus) — Australian pipeline company APA has finished building the Sturt Plateau pipeline (SPP) linking the Beetaloo sub-basin to the 145 TJ/d (3.9mn m³/d) Amadeus gas pipeline, it announced today in its results for its 2025-26 fiscal year ending 30 June. The project to connect Australian shale gas explorer Tamboran Resources' 40 TJ/d Shenandoah South pilot plant is considered the first step to evaluating the region's commercial gas reserves, with potential for the sub-basin to supply domestic gas, LNG terminals and gas-fired data centres under a multitude of plans. First gas from the Shenandoah South pilot plant is due to start in the current quarter, the firm said. Phase 2 of SPP will provide additional compression to increase flows to 100 TJ/d. Phase 3, a proposed northeast Australia pipeline, would be a multi-billion-dollar investment to connect Beetaloo to eastern Australia, including the three LNG projects based at Gladstone in Queensland state. The Northern Territory government has supported the Beetaloo developers by signing binding sales agreements with Tamboran for 40 TJ/d and with Beetaloo Energy, formerly Empire Energy, for up to 25 TJ/d from its pilot plant. The government said this will meet its requirement of 55–60 TJ/d to power essential services. APA approved works to expand capacity on its gas network in the eastern states in February including A$480mn ($342mn) for new compressors, to boost capacity ahead of the 2028 winter months. APA's 2025-26 revenue fell to A$3bn from 2024-25's A$3.2bn, while net profit after tax rose to A$234mn from last year's A$129mn. Capital and investment expenditure was A$845mn, down from A$964mn in 2024-25. Australia is grappling with possible gas shortfalls in southern states from 2029. LNG imports are proposed, which APA strongly opposes, preferring to expand its pipeline grid to supply more gas from developer-friendly northern Australia to Victoria and New South Wales states, where older coal-fired power plants are due to retire, which would lead to higher gas demand for electricity generation . By Tom Major Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.

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Golden Pass LNG flows rise as 7th cargo shipped

19/08/26

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19/08/26

Golden Pass LNG flows rise as 7th cargo shipped

Houston, 19 August (Argus) — Golden Pass LNG exported its seventh cargo from the 18.1mn t/yr (2.4bn ft³/d) terminal in southeast Texas on Tuesday as feedgas flows to the QatarEnergy-ExxonMobil joint venture hit their highest level in six weeks. QatarEnergy's 174,000m³ Umm Heesh departed Golden Pass with a 76,000t cargo early Wednesday bound for Belgium's 11.4mn t/yr Zeebrugge import terminal, Kpler data show. Since 26 June, after the terminal underwent maintenance, Golden Pass has averaged one loading every 13.5 days. This is equivalent to a rate of 2.4mn t/yr, or 40pc of the first liquefaction train's capacity. At full capacity, train 1 can produce about 1.6 cargoes per week, assuming an average cargo size of 72,000t. Wednesday's departure came 14.7 days after the previous loading, a step back from the earlier pace. QatarEnergy's 174,000m³ Umm Wishah departed on 4 August, eight days after ExxonMobil's same-size Esteem Cormorant left on 27 July, Kpler data show. Meanwhile, the terminal received 529mn ft³/d of gas on Tuesday, the highest since 2 July, pipeline data show, as the joint venture commissions the first train. Flows to Golden Pass have averaged 320mn ft³/d over the 30-day period ended 17 August. The facility was preliminarily nominated to receive a record high 588mn ft³ of gas on 19 August, but flows often fluctuate and may be revised later in the day. Trains 2 and 3 were originally planned to come on line in six-month increments. But Golden Pass had to shuffle the setup of its construction contractors after the 2024 bankruptcy of lead contractor Zachry Holdings, which may challenge the six-month cadence, market participants said. By Tray Swanson Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.

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